The Experts below are selected from a list of 60 Experts worldwide ranked by ideXlab platform

Edward L. Hibner - One of the best experts on this subject based on the ideXlab platform.

  • Corrosion Resistant OCTG's and Matching Age-Hardenable Bar Products for a Range of Sour Gas Service Conditions
    Corrosion, 2001
    Co-Authors: Edward L. Hibner, C. S. Tassen
    Abstract:

    In selecting materials for corrosive Sour oil field environments, the materials of choice must be reliable and cost-effective. Materials have to meet criteria for corrosion resistance and mechanical properties in Service environments for the required Service life. Both age-hardened nickel-base alloys and cold-worked solid solution nickel-base alloys offer many advantages such as high-strength, toughness and excellent corrosion resistance. Alloy 028 (UNS N08028), alloy 825 (UNS N08825), alloy G-3 (UNS N06985), alloy 050 (UNS N06950) and alloy C-276 (UNS N10276) are among the primary solid solution high nickel Corrosion Resistant Alloys (CRA's) currently used in the cold worked condition for Oil Country Tubular Goods (OCTG's) in Sour Gas wells. The primary CRA machining quality age-hardened bar products used with alloys 028 and 825 OCTG's for wellhead and subsurface completions of Gas wells are alloy 925 (UNS N09925) and alloy 718 (UNS N07718). The primary CRA machining quality age-hardened bar product used with alloys G-3,050 and C-276 OCTG's for wellhead and subsurface completions of Gas wells is alloy 725 (UNS N07725), the 120 ksi (827 MPa) minimum yield strength grade, and alloy 725HS, the 140 ksi (965 MPa) minimum yield strength grade. This paper presents guideline tables and graphs for cold-worked nickel alloys 028, 825, G-3, 050 and C-276 and agehardened alloys 718, 925 and 725. The primary CRA machining quality age-hardened bar products used with OCTG's are ranked for a range of Sour Service conditions. Based on an extensive literature review of laboratory test and field data, the alloys have demonstrated corrosion resistance up to 230°C (450°F) depending on the chloride concentration, and H2S content. Data are also included for alloy 686 (UNS N06686) and alloys 725 weld overlays and for alloy 25-6MO (UNS N08926) wire lines.

  • corrosion resistant oil country tubular goods and completion alloys for moderately Sour Gas Service
    Stainless steel world, 2000
    Co-Authors: Edward L. Hibner, C. S. Tassen
    Abstract:

    In selecting materials for corrosive Sour oil field environments, the materials of choice must be cost-effective and reliable. Materials have to meet criteria for mechanical properties and corrosion resistance in Service environments for the required Service life. Both age hardened nickel base alloys and cold worked solid solution nickel base alloys offer many advantages such as high-strength, toughness and excellent corrosion resistance Incoloy®, alloy 825 (UNS N08825) and Incoloy® alloy 028 (UNS N08028) are among the primary solid solution Corrosion Resistant Alloys (CRAs) currently used in the cold worked condition for Oil Country Tubular Goods (OCTGs) in moderately Sour Gas wells. The primary CRA machining quality age hardened bar products used with alloys 825 and 028 OCTGs for wellhead and subsurface completions of Gas wells are Incoloy® alloy 925 (UNS N09925) and Inconel®, alloy 718 (UNS N07718).

  • Effect of alloy nickel content vs PREN on the selection of austenitic oil country tubular goods for Sour Gas Service
    Corrosion, 1998
    Co-Authors: Edward L. Hibner, Steve Tassen, James W. Skogsberg
    Abstract:

    Traditionally, in the selection of Oil Country Tubular Goods (OCTG) for Sour Gas Service, Corrosion Resistant Alloys (CRA`s) are screened first by their pitting resistance equivalent number (PREN) and then by environmental cracking data generated in Sour brine environments. The theory is that a pit occurs first, which provides a stress-riser for initiation of anodic chloride stress corrosion cracking (KC). Among the primary CRA`s currently used in the cold worked condition for OCTG in Sour Gas wells are alloy 825 (UNS N08825) and alloy 28 (UNS N08028). While alloy 28 has a somewhat higher PREN than alloy 825, alloy 825 has a significantly higher nickel content. Slow strain rate (SSR) tests conducted in severe Sour brine environments showed that the higher nickel content of alloy 825 results in better stress corrosion cracking resistance than that exhibited by alloy 28. The effect of nickel content on chloride SCC resistance of austenitic alloys was originally reported by H.R. Copson in 1959. This suggests that in some cases for austenitic alloys, the nickel content of the CRA may be more important than the PREN in OCTG selection.

  • Evaluation of corrosion testing techniques for selection of corrosion resistant alloys for Sour Gas Service
    Corrosion, 1996
    Co-Authors: Edward L. Hibner, Rashmi B. Bhavsar
    Abstract:

    Slow strain rate (SSR) and C-ring stress corrosion cracking (SCC) tests have historically been used to screen alloys for Sour Gas environments. The relevance of these testing techniques in predicting actual field corrosion behavior was evaluated for age-hardenable nickel base alloy 925 (UNS N09925) and alloy 718 (UNS N07718). While SSR testing provides an acceptable accelerated screening tool for ranking alloys in Sour oil field environments, C-ring SCC testing ranks alloys higher in Sour environments than SSR testing.

C. S. Tassen - One of the best experts on this subject based on the ideXlab platform.

  • Corrosion Resistant OCTG's and Matching Age-Hardenable Bar Products for a Range of Sour Gas Service Conditions
    Corrosion, 2001
    Co-Authors: Edward L. Hibner, C. S. Tassen
    Abstract:

    In selecting materials for corrosive Sour oil field environments, the materials of choice must be reliable and cost-effective. Materials have to meet criteria for corrosion resistance and mechanical properties in Service environments for the required Service life. Both age-hardened nickel-base alloys and cold-worked solid solution nickel-base alloys offer many advantages such as high-strength, toughness and excellent corrosion resistance. Alloy 028 (UNS N08028), alloy 825 (UNS N08825), alloy G-3 (UNS N06985), alloy 050 (UNS N06950) and alloy C-276 (UNS N10276) are among the primary solid solution high nickel Corrosion Resistant Alloys (CRA's) currently used in the cold worked condition for Oil Country Tubular Goods (OCTG's) in Sour Gas wells. The primary CRA machining quality age-hardened bar products used with alloys 028 and 825 OCTG's for wellhead and subsurface completions of Gas wells are alloy 925 (UNS N09925) and alloy 718 (UNS N07718). The primary CRA machining quality age-hardened bar product used with alloys G-3,050 and C-276 OCTG's for wellhead and subsurface completions of Gas wells is alloy 725 (UNS N07725), the 120 ksi (827 MPa) minimum yield strength grade, and alloy 725HS, the 140 ksi (965 MPa) minimum yield strength grade. This paper presents guideline tables and graphs for cold-worked nickel alloys 028, 825, G-3, 050 and C-276 and agehardened alloys 718, 925 and 725. The primary CRA machining quality age-hardened bar products used with OCTG's are ranked for a range of Sour Service conditions. Based on an extensive literature review of laboratory test and field data, the alloys have demonstrated corrosion resistance up to 230°C (450°F) depending on the chloride concentration, and H2S content. Data are also included for alloy 686 (UNS N06686) and alloys 725 weld overlays and for alloy 25-6MO (UNS N08926) wire lines.

  • corrosion resistant oil country tubular goods and completion alloys for moderately Sour Gas Service
    Stainless steel world, 2000
    Co-Authors: Edward L. Hibner, C. S. Tassen
    Abstract:

    In selecting materials for corrosive Sour oil field environments, the materials of choice must be cost-effective and reliable. Materials have to meet criteria for mechanical properties and corrosion resistance in Service environments for the required Service life. Both age hardened nickel base alloys and cold worked solid solution nickel base alloys offer many advantages such as high-strength, toughness and excellent corrosion resistance Incoloy®, alloy 825 (UNS N08825) and Incoloy® alloy 028 (UNS N08028) are among the primary solid solution Corrosion Resistant Alloys (CRAs) currently used in the cold worked condition for Oil Country Tubular Goods (OCTGs) in moderately Sour Gas wells. The primary CRA machining quality age hardened bar products used with alloys 825 and 028 OCTGs for wellhead and subsurface completions of Gas wells are Incoloy® alloy 925 (UNS N09925) and Inconel®, alloy 718 (UNS N07718).

James W. Skogsberg - One of the best experts on this subject based on the ideXlab platform.

  • Effect of alloy nickel content vs PREN on the selection of austenitic oil country tubular goods for Sour Gas Service
    Corrosion, 1998
    Co-Authors: Edward L. Hibner, Steve Tassen, James W. Skogsberg
    Abstract:

    Traditionally, in the selection of Oil Country Tubular Goods (OCTG) for Sour Gas Service, Corrosion Resistant Alloys (CRA`s) are screened first by their pitting resistance equivalent number (PREN) and then by environmental cracking data generated in Sour brine environments. The theory is that a pit occurs first, which provides a stress-riser for initiation of anodic chloride stress corrosion cracking (KC). Among the primary CRA`s currently used in the cold worked condition for OCTG in Sour Gas wells are alloy 825 (UNS N08825) and alloy 28 (UNS N08028). While alloy 28 has a somewhat higher PREN than alloy 825, alloy 825 has a significantly higher nickel content. Slow strain rate (SSR) tests conducted in severe Sour brine environments showed that the higher nickel content of alloy 825 results in better stress corrosion cracking resistance than that exhibited by alloy 28. The effect of nickel content on chloride SCC resistance of austenitic alloys was originally reported by H.R. Copson in 1959. This suggests that in some cases for austenitic alloys, the nickel content of the CRA may be more important than the PREN in OCTG selection.

Malcolm Geoffrey Hay - One of the best experts on this subject based on the ideXlab platform.

  • fitness for purpose material testing for Sour Gas Service an overview
    Corrosion, 2001
    Co-Authors: Malcolm Geoffrey Hay
    Abstract:

    Abstract Sour environments differ significantly in their aggressiveness toward materials, depending on such factors as total system pressure, partial pressures of hydrogen sulfide (H2S) and carbon dioxide (CO2), pH of the aqueous phase, temperature, chloride ion (Cl−) concentration, etc. Materials that perform poorly in standard laboratory sulfide stress cracking and hydrogen-induced cracking tests and some field environments may give acceptable performance under other Sour Service conditions. This paper provides some additional guidance on the manner in which standard Sour Service testing methods should be selected and performed, and on the interpretation and application of the results. The relevant recommendations and requirements of NACE International, the European Federation of Corrosion (EFC), and the American Petroleum Institute (API) are reviewed. The recommendations of NACE, EFC, and API for the selection of the most appropriate test method(s), test frequency, and acceptance criteria for particula...

  • Fitness-for-Purpose Material Testing for Sour Gas Service—An Overview
    CORROSION, 2001
    Co-Authors: Malcolm Geoffrey Hay
    Abstract:

    Abstract Sour environments differ significantly in their aggressiveness toward materials, depending on such factors as total system pressure, partial pressures of hydrogen sulfide (H2S) and carbon dioxide (CO2), pH of the aqueous phase, temperature, chloride ion (Cl−) concentration, etc. Materials that perform poorly in standard laboratory sulfide stress cracking and hydrogen-induced cracking tests and some field environments may give acceptable performance under other Sour Service conditions. This paper provides some additional guidance on the manner in which standard Sour Service testing methods should be selected and performed, and on the interpretation and application of the results. The relevant recommendations and requirements of NACE International, the European Federation of Corrosion (EFC), and the American Petroleum Institute (API) are reviewed. The recommendations of NACE, EFC, and API for the selection of the most appropriate test method(s), test frequency, and acceptance criteria for particula...

Jean-marc Lardon - One of the best experts on this subject based on the ideXlab platform.

  • Superduplex Stainless Steel Use in Manufacturing Highly Sour Gas Centrifugal Compressors
    Volume 3: Coal Biomass and Alternative Fuels; Combustion and Fuels; Oil and Gas Applications; Cycle Innovations, 1996
    Co-Authors: François Millet, Patrick Friez, Angelo Franzi, Bernard Bonnefois, Jean-marc Lardon
    Abstract:

    More and more often, oil fields need to handle wet Sour Gases which contain high proportions of carbon dioxide and hydrogen sulphide. Furthermore, the liquid phase contains water with chlorides. Therefore, pitting corrosion and stress corrosion cracking may occur. Centrifugal compressors used on oil fields for increasing the pressure levels, require components which must be resistant to be efficient, but nevertheless cheap for an industrial solution. A corrosion resistant material with high mechanical characteristics is necessary. Duplex stainless steels which have been widely developed and experimented on off-shore applications, are a good way to achieve this challenge. They must be solution annealed to withstand severe corrosion conditions. This paper deals with the metallurgical aspects and the major influence of heat treatments, and with the manufacturing process of two major components : the casing and the rotor. This new centrifugal compressor, designed for a highly Sour Gas Service, with 87% of acid compoaents, is dedicated to a process of sulphur elimination from the flare Gas for environmental protection reasons. It has been operating since the beginning of 1995 by GasCO in Abu Dhabi.Copyright © 1996 by ASME